Other

Tam International, Inc.

Lawrence Sanford

Charles O Stokley

Edwin C Turner

Charles O Stokely

James M Mounteer

Ronald A Jordan

Improved methods and apparatus are provided for obtaining multiple fluid samples from subterranean formations of interest. The present invention is particularly well suited for testing nuclear migration in ground water utilizing test wells surrounding a nuclear test site. A plurality of flow ports are provided in the casing each at a depth of a formation of interest, and a sliding sleeve is positioned over each port. A wireline tool is lowered to the selective depth, and downhole electric motor energized to power a pump and pass pressurized fluid to move a first dog radially outward. The downhole tool may be axially moved until the first dog locks into a groove provided in the casing. Fluid entering the casing is sealed above and below the sliding sleeve. Fluid pressure may then be applied to move a second dog radially outward to engage the sliding sleeve, and a control valve regulated to apply fluid pressure to axially move the sleeve and open the port. Entering fluid may be tested by a downhole tester, and a signal transmitted to the surface. If the fluid is determined to be representative of the downhole fluid to be tested, fluid is then passed to a chamber within the downhole tool so that it may subsequently be retrieved to the surface. The release of hydraulic pressure allows the dogs to disengage from the casing and the sliding sleeve, and the tool may be moved to another depth. Using the procedures of the present invention, multiple fluid samples may be reliably obtained at selected depths with a single wireline run, thereby substantially reducing costs.

Apparatus for obtaining subterranean fluid samples

Method and apparatus for obtaining subterranean fluid samples

Improved methods and apparatus are provided for sealing at the uppermost end of a casing string to provide circulation from adjacent the lower end of the casing string and into a well bore to enable the casing string to be more easily lowered into the well bore. A casing circulator is provided for lowering into the uppermost end of the casing string above the rig floor, and for sealing with an interior surface of the uppermost end of the casing string. An external sealing member of the casing circulator may be moved axially with respect to an inner packer tube, thereby allowing the sealing member to become inflated while also enabling fluid to pass through the casing circulator and into the casing string. The techniques of the present invention may also be used to fill the casing string as it is lowered into the well bore.

Casing circulator and method

An inflatable packer is provided for setting downhole in an oil or gas well to prevent fluid flow past the packer. The packer is of the type which includes an upper and lower packer head, an inflatable elastomer bladder, a radially outward tubular packer cover, and a plurality of overlapping metal reinforcing members positioned in the annulus between the bladder sleeve and the tubular packer cover. Each reinforcing member is slidably movable relative to another reinforcing member during setting of the packer, and includes a stop member between the packer heads for limiting to a preselected amount the relative sliding movement, such that gaps between reinforcing members are minimized or eliminated. These stop members on the reinforcing members may be formed by a stamping operation, wherein a recess stamped in one reinforcing member is adapted to receive a lip stamped in an adjacent reinforcing member. When the lip drops within the recess, further sliding movement between those reinforcing members is prohibited. Each of the reinforcing members preferably includes an interior surface substantially parallel to the outer surface of the bladder sleeve when the packer is inflated. The concepts of the present invention substantially reduce the likelihood of rupture of the bladder, thereby enhancing the reliability of an inflatable packer.

Inflatable packer with improved reinforcing members

A downhole tool is provided suitable for multiple setting and unsetting operations in a well bore during a single trip. The downhole tool is suspended in the wellbore from a tubing string, and is activated by dropping a metal ball which plugs the passageway through the tubing string, such that tubing pressure may thereafter be increased to activate the downhole tool. A sleeve is axially movable within a control sub from a ball stop position to a ball release position, and has a cylindrical-shaped interior surface with a diameter only slightly greater than the ball. Collet fingers carried on the sleeve are radially movable from an inward position to an outward position to stop or release the ball as a function of the axial position of the sleeve. Fluid flow through the tubing string is thus effectively blocked when the sleeve is in the ball stop position because of the close tolerance between the sleeve and the ball, while the ball is freely released from the sleeve and through the downhole tool when the sleeve is moved to the ball release position.

Multiple-set downhole tool and method

A packer assembly is provided suitable for multiple setting and unsetting operations in a well bore during a single trip to seal the annulus between the interior walls of the well bore and a tubing string. Thge packer is set by dropping a metal ball which plugs the passageway through the tubing string, such that tubing pressure may thereafter be increased to inflate the packer. A sleeve is axially movable within a control sub from a ball stop position to a ball release position, and has a cylindrical-shaped interior surface with a diameter only slightly greater than the ball. Collet fingers carried on the sleeve are radially movable from an inward position to an outward position to stop or release the ball as a function of the axial position of the sleeve. Fluid flow through the tubing string is thus effectively blocked when the sleeve is in the ball stop position because of the close tolerance between the sleeve and the ball, while the ball is freely released from the sleeve and through the packer assembly when the sleeve is moved to the ball release position.

Multiple-set packer and method

An inflatable packer for sealing across downhole conduits comprises a pair of rigid tubular packer heads coaxially interconnected by an inflatable tubular packer body. A bladder in the form of an elongate, flexible elastomeric sleeve includes a central section lining the packer body and having an outer diameter which, in a relaxed state of the bladder, is less than the deflated inner diameter of the packer body. The central section of the bladder is folded upon itself within the packer body in its deflated configuration. An inner reinforcing layer of the packer body is exposed in an annular area between the ends of the packer body.

Inflatable well packer

A downhole packer assembly includes a first packer tool with a flexible tubular packer body which is radially extendable by virtue of fluid pressure in a packer set chamber. A generally annular packer foundation, including an upper packer head, is connected to the upper end of the packer body. The tool defines a bypass flow system for permitting flow of fluid from the packer set chamber to a central longitudinal flowway of the assembly and from this central flowway to the exterior of the assembly. A control sub adjacent the packer foundation is movable with respect to the packer foundation between a first position, for opening the bypass system, and a second position, closing the bypass system. The control sub is preferably further operative, in its first position, to permit communication between the central flowway and the packer set chamber, and in its second position, to close the packer set chamber. A second packer tool is connected in tandem with the first tool. A ported cylinder is communicatively connected to the packer foundations generally below the locus of the control sub and has a piston reciprocably disposed therein and sealed with respect thereto, the piston being yieldably urged toward the control sub. A plug ejector may be adjoined to the upper packer head of the first tool and disposed therein but adapted to permit flow therethrough. The plug ejector has a free end extending upwardly and positioned for telescopic movement with respect to the lower end of the control sub as it moves between its inflation and set positions.

Packer assembly

A dual packer apparatus comprises a tubular outer assembly including upper and lower packers interconnected and spaced apart by tubular spacers. Ports in the outer assembly provide for communication with a well zone between the two packers and a well zone below the lower packer. A tubular inner assembly may be separately assembled and inserted into the outer assembly as assembled. The apparatus may be alternately placed in a number of different operating positions downhole by manipulation of an operating string attached to the inner assembly. Various design features provide special protection for annular seals between the two assemblies. An improved sensor and method of installing the sensor in the inner assembly are also provided.

Dual packer apparatus and method

An inflatable packer which can be easily constructed using tubular members such as a section of well casing, the packer having spaced, first and second annular heads which surround a central tubular member, the first head being slidable along the tubular member, a relief or attachment space being formed between the second head and the tubular member, a securing element being disposed in the relief for securing the second head to the tubular member and preventing relative longitudinal movement thereof, a centering member being disposed between the second head and the tubular member to maintain the second head and the tubular member in substantially coaxial relationship independent of the securing element, an inflatable, tubular element being attached to and extending between the first and second heads.

Inflatable packer construction

The invention comprises an inflatable packer comprising a tubular mandrel having a port extending radially therethrough. An elastomeric valve element is resiliently urged against the exterior of the mandrel to cover the port. A generally tubular packer body surrounds the mandrel and comprises a pair of longitudinally spaced apart heads, one of which is longitudinally slidable on the mandrel, and a tubular radially expandable packer element interposed between the heads. Fluid communication is provided between the radially outer side of the said port and a fluid reception chamber. The packer body is operatively associated with the chamber and responsive to fluid pressure therein to radially extend the packer element.

Inflatable packer

A tool for running in and/or retrieving a bore protector, the tool comprising first and second assemblies longitudinally slidably connected to each other. Latches are mounted on the first assembly for lateral extension and retraction with respect thereto. The latches are also cooperatively connected to the second assembly for laterally inward movement of the latches upon longitudinal movement of the second assembly relative to the first assembly in a first direction, and for laterally outward movement of the latches upon longitudinal movement of the second assembly relative to the first assembly in a second direction opposite the first direction. Means are provided for selectively moving the second assembly in the first direction, and the latches are yieldably biased laterally outwardly. The invention further includes a bore protector adapted for use with the tool by the provision of the internal latch engagement formations. A method of protecting a bore with the bore protector and tool is also disclosed.

Apparatus and method for protecting well bore

An inflatable packer including a tubular mandrel having generally radial ports therethrough and a sub slidably telescopically mounted on the mandrel. A first annular space, in communication with the ports, is formed between the mandrel and the sub. An inflatable packer element is carried by the sub, the mandrel extending through the packer element such that a second annular space is formed between the mandrel and the packer element. A valve mechanism is disposed in the first annular space and includes an annular seal means and a locking mechanism. The seal means is operative upon the presence of pressure differential decreasing thereacross toward the second space to permit fluid flow through the first annular space from the ports to the second annular space and inflate the packer element. The seal means is further operative upon the presence of pressure differential decreasing thereacross toward the ports to form a seal between the ports and the second annular space. The locking mechanism is operatively associated with the seal means to lock the mandrel against upward movement with respect to the sub upon the presence of the last mentioned pressure differential. An upward pull on the mandrel releases the locking mechanism to break the seal and deflate the packer element.

Inflatable packer and valve mechanism therefor

A single trip method of testing and treating a down hole formation in which conventional drill stem testing can be carried out followed by acidizing or other treatment of the formation without the need to remove the drill stem test string, the method employing a well tool in the operating tool string which allows reverse circulation to clean out the tool string following the initial drill stem test, allows the introduction of acidizing fluid into the formation and permits a second reverse circulation following acidizing and subsequent testing, the well tool being operative without the necessity for rotation of the tool string.

Growing community of inventors

Houston, TX, United States of America

Lawrence Sanford